A bottom hole assembly (BHA) and method for drilling a bore with a pneumatic percussion hammer includes an expandable packer surrounding the stem rod connected to the hammer. The packer has an inner surface confronting the outer surface of the stem rod in an axially slideable, sealed relationship. The packer is expanded and fixed in the bore to separate a region of high hydraulic pressure above the packer from a region of lower hydraulic pressure below the packer. The method includes operating the pneumatic hammer and bit, while (i) the stem rod advances with a sliding seal against an inside surface of the expanded packer; (ii) pneumatic pressurization and exhaust for the hammer are guided within the stem rod; and (iii) the exhaust from the hammer is discharged into the lower clearance region surrounding the bit at the bottom of the bore.

A connector secures an ESP to coiled tubing containing a power cable. Upper and lower barriers in the connector housing define an upper chamber, a lower chamber, and a center chamber. An upper chamber dielectric fluid in the upper chamber is in fluid communication with the interior of the coiled tubing. A lower chamber dielectric fluid in the lower chamber is in fluid communication with motor lubricant in the motor of the ESP. Center chamber dielectric fluid in the center chamber is sealed from contact with the upper and lower chamber dielectric fluids by the upper and lower barriers. A thermal expansion device has a container portion for allowing center chamber dielectric fluid to expand into the container.

A dual telemetric coiled tubing running string for disposing a bottom hole assembly into a wellbore. The dual telemetric coiled tubing running string includes a string of coiled tubing which defines a flowbore along its length, an electrical wire conduit disposed within the flowbore, and an optic fiber disposed within the flowbore

A dual coiled tubing head has an outer coiled tubing connector, an inner coiled tubing connector, a central housing and a bottom housing. The inner coiled tubing connector fits within the outer coiled tubing connector such that a passage is created between the inner coiled tubing connector and the outer coiled tubing connector to allow for the passage of fluid through the outer coiled tubing connector. A central housing is connected to the outer and inner coiled tubing connectors. The central housing has a central passage, a peripheral downhole passage and an outlet. The peripheral downhole passages are in fluid communication with the outer coiled tubing connector. The bottom housing connects to the central housing. The bottom housing has a central passage. The central passage is in fluid communication with the peripheral downhole passages for permitting downhole flow of fluid from the exterior coiled tubing connector.

A method includes introducing a first liquid composition into a well having a wellbore, introducing a second liquid composition into the well, and mixing the first and second liquid compositions within the well. The first liquid composition is kept separate from the second liquid composition until mixing the first and second liquid compositions within the well. Furthermore, the first liquid composition includes a first reactive component, the second liquid composition includes a second reactive component, and the first reactive component reacts with the second reactive component in response to mixing the first and second liquid compositions within the well. The method further includes causing the mixed compositions to engage the wellbore. In one example, the first reactive component may be an epoxy and the second reactive component may be a hardener that reacts with the epoxy to form a solid plug in the wellbore to seal off the well.

An apparatus and system for generating pressure pulses and gathering down-hole sensory information for enhancing and completing a well bore within a coiled tubing operation including: a valve longitudinally and axially positioned within the center of a pulser section and electronics to transmit and record down-hole sensory information. The main fluid flow is interrupted by the main valve which is operated by the controlled pilot fluid stream. The main fluid flow proceeds toward one or more pressure sensors to measure the fluid flow pressure with sensors that send signals to a Digital Signal Processor (DSP) that controls a valve which generates controllable and measurable energy pulses. Recorded downhole sensory information such as temperature, fluid bore and annulus pressure, weight/axial force, torque, vibration, shock, gravity tool-face, casing collar locator, gamma, flow and battery condition can be transmitted in real-time via pressure pulses to the surface with pulser or downloaded for analysis.

A technique provides for management of multiple flow assurance functionalities in a pipe-in-pipe system. A station for use in a subsea pipe-in-pipe system may comprise an inner flow conduit to provide an inner flow passage for a first fluid and an outer flow conduit to provide an annular flow passage for a second fluid. The station also may comprise a network of valves and conduits coupled to the inner flow conduit and to the outer flow conduit. The valves are individually adjustable to enable selection of multiple flow assurance functionalities so as to ensure continued fluid flow capability following a plug. Depending on the parameters of a given application, a plurality of the stations may be combined with a plurality of pipe-in-pipe sections to form a suitable subsea pipe-in-pipe system.

A downhole motor for directional drilling includes a driveshaft assembly including a driveshaft housing and a driveshaft rotatably disposed within the driveshaft housing. In addition, the downhole motor includes a bearing assembly including a bearing housing and a bearing mandrel rotatably disposed within the bearing housing. The bearing mandrel has a first end directly connected to the driveshaft with a universal joint and a second end coupled to a drill bit. Further, the downhole motor includes an adjustment mandrel configured to adjust an acute deflection angle between the central axis of the bearing housing and the central axis of the driveshaft housing. The adjustment mandrel has a central axis coaxially aligned with the bearing housing, a first end coupled to the driveshaft housing, and a second end coupled to the bearing housing.

In a coiled tubing assembly for use in a wellbore, the tubing assembly uses longitudinally spaced apart clamping members to clamp two or more coiled tubing members alongside one another. Each clamping member includes a clamping portion extending circumferentially about each coiled tubing member so as to be rotatable in relation thereto, and a connecting portion joined between the clamping portions. A longitudinal positioning element is fixed relative to one of the tubing members in association with each clamping member such that the clamping member remains pivotal relative to the positioning element and the tubing members upon which it is fixed. The longitudinal positioning element thus only restricts the respective clamping assembly in the longitudinal direction along the tubing members without restricting relative twisting between the tubing members.

A repeatedly usable downhole pumping assembly including; a conduit comprising a plurality of pipes, wherein the pipes are uniformly entwined together along their length to provide multiple fluid passageways, wherein the conduit is to be wound onto a reel and off the reel repeatedly; a rotatably mounted reel, upon which the conduit is adapted to be wound without collapsing; a pump for pumping fluid through the conduit; and a driving means to lower and raise the conduit relative to the bore.